| Resource Type | Webinar |
| Author / Source | Co-op Innovation Network (CIN) |
| Publication Date | October 2025 |
| Location | Multi-state (MN, VT, CO); lessons applicable nationally |
| Initiative Type | Program, Technology |
| Project Complexity | Intermediate |
| Recommended For | Board, Staff |
Estimated viewing time: 35 minutes
Why This Matters for Rural Electric Co-ops
Transmission and capacity costs are rising sharply across regions, putting pressure on co-op rates and creating urgency to find non-wires alternatives. Battery storage, deployed at residential, community, or substation scales, gives co-ops a tool to reduce coincident peak demand, defer expensive substation upgrades, and integrate growing distributed solar without curtailing interconnection.
The three case studies show distinct strategies a co-op can adapt based on its size, territory, and power supply arrangement, including bring-your-own-battery programs, settings-based residential rebates, and utility-owned substation batteries. Co-op leaders can use this resource to evaluate which storage model best matches their load profile, capital constraints, and member adoption patterns.
Key Takeaways
| › | Bring-your-own-battery programs can compensate members for dispatching residential batteries against transmission peaks, with per-site value driven by accuracy in forecasting peak windows. |
| › | Substation-sited batteries can defer transformer upgrades when load growth is moderate and the next standard transformer size would create wasted capacity. |
| › | Settings-based rebate programs offer a low-cost on-ramp for co-ops that lack scale or vendor partners for a full virtual power plant DERMS platform, and can later evolve into VPP models as adoption grows. |
| › | Bonus incentives tied to specific feeders experiencing reverse power flow can use residential batteries to prop up minimum daytime load and unlock additional solar interconnection capacity. |
Implementation Considerations
- Cost or Funding Requirements: Utility-scale projects require significant capital and long lead times (Connexus's project ran from 2021 scoping to May 2025 commissioning), while residential rebate programs can launch with modest budgets but depend on accurate ROI assumptions about per-system peak reduction and availability rates.
- Staffing or Technology Requirements: SCADA-based real-time dispatch reduces handoff errors compared to scheduled dispatch through third-party control centers, but requires engineering capacity to manage. Smaller co-ops without DERMS budgets can use settings verification (authorized user access or installer-reported quarterly data) as a lighter-weight alternative to full aggregation software.
Notable Examples
- Vermont Electric Cooperative: Operates a bring-your-own-battery program with 200+ residential devices, paying roughly $35/month per two-Power Wall system to dispatch against 13 annual transmission peaks, plus five developer-owned utility-scale sites totaling about 4.5 MW.
- Connexus Energy: Commissioned a 10 MWh / 2.5 MW substation battery (built by NextEra) at Vadnais Heights to defer a transformer upgrade from two 10.5 MVA units to two 28 MVA units.
- La Plata Electric Association: Its "set it and forget it" rebate program ($1,000–$2,000 per battery, roughly 10% of system cost) drove a 4x year-over-year increase in installations and is achieving 0.8 kW of peak demand reduction per system.
- Green Mountain Power: Referenced as a Vermont peer whose programs informed VEC's approach.
Estimated viewing time: 35 minutes
Related to
Comments
0 comments
Please sign in to leave a comment.